Latest / Energy Economics with Fexingo: Oil Prices, Renewables, and the Cost of Power / Why LNG Export Capacity Is Becoming a Strategic Liability
Transcript
- Lucas: Luna, I want to put a question to you that I think cuts to a really uncomfortable dynamic in energy markets right now. The United States is now the world's largest exporter of liquefied natural gas. We have more LNG export capacity than Qatar and Australia. And on paper, that's a huge win for American energy dominance. But I'm starting to wonder if we've actually built ourselves a new vulnerability. Luna: A vulnerability how? I mean, more exports usually means more demand for our gas, which is good for producers, good for the trade balance. Where's the downside? Lucas: The downside is that the same LNG terminals that let us ship gas to Europe and Asia also tie the domestic price of natural gas — the stuff that heats homes and powers about 40 percent of US electricity — to global commodity markets that are increasingly volatile. And we've seen that volatility spike just this week. Henry Hub futures dropped four point six percent in the last five days to about three oh eight per million BTUs. But that drop is not purely a US supply story. It's being driven by global demand fears tied to the escalation between Iran and the US — strikes on Iranian assets over the weekend, retaliation threats against Bahrain, Kuwait, Jordan. That's injecting risk premiums into Brent crude, but it's also dragging on gas because traders are pricing in a potential demand shock if the conflict broadens. Luna: So the same geopolitical turmoil that pushes oil up can push US gas down, because it signals weaker economic activity globally. But that's just short-term trading noise, right? The structural concern is something else? Lucas: Exactly. The structural concern is that these export terminals operate on long-term 'take or pay' contracts. The buyers — usually Asian or European utilities — have committed to buying a certain volume of LNG every year, whether they need it or not. And US producers have committed to supplying it. So when a cold snap hits the Midwest in January and local gas demand spikes, the molecules are already spoken for. They're going to a ship in the Gulf, not to a heating plant in Ohio. That's a real physical constraint we didn't have a decade ago. Luna: That is a genuinely scary scenario. And it's not hypothetical — we saw something similar in Europe during the 2022 energy crisis, where French and German utilities had to pay astronomical prices because their gas was tied up in Asian contracts. So you're saying the US could face its own version of that? Lucas: I think it's more likely than most people realise. And it's worth pausing here, because this show depends on listeners like you to stay independent and dig into exactly these kinds of structural risks. If walking through the energy economy with us has made something click — if you feel like you understand the market a little better because of these conversations — you can support the show at buy me a coffee dot com slash fexingo. That helps us keep the episodes ad-free and focused on the numbers that matter. No pressure, just an option if the work is valuable to you. Luna: Absolutely. It makes a real difference for us to have that listener support, especially when we're covering topics that don't get a lot of airtime elsewhere. And now back to those LNG contracts — I want to understand the scale. How much of our export capacity is locked into these take or pay deals? Lucas: Roughly seventy to eighty percent of the volume from the big terminals — Sabine Pass, Corpus Christi, Freeport — is under long-term contracts with durations of fifteen to twenty-five years. The remaining spot capacity is what traders fight over, but the core flows are fixed. And the thing is, those contracts were signed when US gas was dirt cheap and Henry Hub was below three dollars. Now European gas prices are five, six times higher, so those buyers are still getting a great deal. But if US demand ever surges — say, due to a polar vortex or a sudden spike in power plant retirements — the domestic price would have to rise a lot to attract spot cargoes away from export. And that's the transmission mechanism: global gas prices directly infect US household bills. Luna: So the cure for high global gas prices becomes higher US gas prices. That's a nasty feedback loop. And you've got to think utilities are starting to hedge against this scenario differently than they did five years ago. Lucas: They are. I spoke with a risk manager at a Midwestern utility last month — off the record — and he told me they've doubled their hedge tenors on gas procurement. They used to hedge one to two years out. Now they're going three to five years, locking in physical supply agreements with producers that include firm transport capacity on pipelines that don't even connect to LNG terminals. They're basically trying to wall themselves off from the global market. But that costs money, and those costs flow through to your electricity bill. Luna: And those higher electricity bills show up in inflation data. The April CPI came in at 332.4, up from 330.29 in March. Core CPI excluding food and energy was up too, but the energy components are a big part of the headline stickiness. If gas prices spike this winter because of an LNG contract squeeze, that's going to make the Fed's job even harder. Lucas: Exactly. The ten-year breakeven inflation rate is already at 2.33 percent — down from 2.35, but still above where the Fed wants it. And that's without a gas shock. Now, the counterargument — and I want to give it a fair hearing — is that export capacity also provides a floor under domestic prices when supply is abundant. Without LNG exports, Henry Hub might have fallen below two dollars during the mild winter we just had. So there's a trade-off: you get price support on the downside, but you import volatility on the upside. Luna: That's the classic commodities argument for open markets. But the political reality is that voters don't notice when their gas bill is lower than it would have been. They notice when it spikes. And if a spike is caused by a war in the Middle East that the US is involved in, that's a very potent political narrative. Lucas: And that narrative is already being tested. Iran has threatened Bahrain, Kuwait, and Jordan after US strikes on Iranian assets. Brent crude is up to 98 dollars, WTI at 96. China's wholesale inflation hit a near four-year high in May, partly because of higher input costs from the Iran conflict. So the geopolitical risk premium is spreading through the entire energy complex. And US LNG is right in the crosshairs, because a lot of that gas is destined for Asian buyers who are now paying more for shipping and insurance on routes near the Strait of Hormuz. Luna: But wait — US LNG goes mostly to Europe and Asia, but not through the Strait of Hormuz. That's for Persian Gulf producers. So why would insurance premiums affect US cargoes? Luna: Because the global market is a single pool. If one major shipping route becomes riskier, the cost of all LNG shipping rises as vessels are rerouted and insurance underwriters raise premiums across the board. A US cargo going to Japan might now avoid the Red Sea and go around the Cape of Good Hope, adding ten to fifteen days to the voyage. That increases the delivered cost, which puts upward pressure on the global benchmark price — and that feeds back to Henry Hub via the arbitrage channels I mentioned. Luna: So the US is effectively importing Middle Eastern risk through its own export infrastructure. That is a remarkable irony. The whole point of the LNG buildout was energy independence. Lucas: Energy independence in terms of production, but not in terms of price. We can produce all the gas we need, but if we've signed long-term contracts to sell it abroad, we are exposed to global demand and geopolitical shocks anyway. And here's the really uncomfortable number: US LNG export capacity is set to roughly double by 2030, with new terminals like Venture Global's Plaquemines and Cheniere's Corpus Christi Stage Three coming online. That means the share of US production exposed to global pricing is going to rise from about 15 percent today to maybe 30 percent by the end of the decade. Luna: Thirty percent of US gas production linked to global prices. That's huge. And it means utility regulators in states like Ohio, Indiana, and Georgia need to start thinking about this as a systemic risk, not just a trading desk problem. Lucas: Exactly. And some of them are. The Federal Energy Regulatory Commission, FERC, recently held a technical conference on LNG export impacts on domestic reliability. But there's no binding requirement for exporters to reserve a portion of their capacity for the domestic market in emergencies. The market design assumes that high prices will attract supply back — but as we saw in Texas during Winter Storm Uri, the physical reality is that pipelines and storage can't always deliver when it's negative 10 degrees and everyone is competing for the same molecules. Luna: So what's the fix? Do we need a strategic gas reserve like we have for oil? Or a requirement that a share of LNG contracts include a domestic break clause? Lucas: Both ideas have been floated. A strategic gas reserve would be enormously expensive — you'd need to store something like 500 billion cubic feet of gas, plus the infrastructure to inject and withdraw it. That could cost tens of billions. A domestic break clause would renegotiate existing contracts, which would trigger lawsuits and potentially undermine US credibility as a reliable supplier. Europe and Asia came to us precisely because they wanted an alternative to Russian pipeline gas — if we now say 'sorry, we might need that gas back in a cold snap,' they'll go elsewhere. Luna: So there's no easy answer. It's a structural tension between the commercial logic of long-term contracts and the political logic of domestic energy security. Lucas: And that tension is only going to grow as export capacity expands and the global gas market becomes more integrated. We're moving from a world where US gas prices were largely set by domestic supply and weather — think the old Henry Hub of the 2010s, bouncing between two and four dollars — to a world where they are increasingly correlated with Asian spot prices and European storage levels. That's a big shift, and I don't think the public fully understands it yet. Luna: And what about the climate angle? Because if US gas prices spike, that makes coal more competitive in the power stack. We could see emissions go up as utilities switch back to coal-fired generation. Lucas: That's the worst-case irony. The US has reduced power sector emissions largely by switching from coal to gas. If gas becomes too expensive or too uncertain, coal plants that were slated for retirement might get a second life. We're already seeing that dynamic in Europe — German coal burn rose in 2022 and 2023 during the gas crisis. So the LNG export boom, which was supposed to help the world decarbonise by displacing coal abroad, could end up increasing US emissions at home. Luna: So the net climate impact of US LNG depends on whether it displaces more coal in Asia than it adds coal in the US. That's a highly uncertain calculus, and it changes with every geopolitical shock. Lucas: Exactly. And that's why I think the conversation around LNG has to move beyond just 'exports good, more revenue.' It's a strategic asset, but it's also a strategic liability. And the question for policymakers — and for investors — is whether the liability is priced in. I don't think it is. The futures curve for Henry Hub out to 2028 is still in the three-dollar range. That implies the market thinks the current geopolitical risk is transient. But what if it's not? Luna: That's the million-dollar question. And I think we'll be revisiting it a lot over the next year. Lucas, great conversation as always. Lucas: Thanks, Luna. And thanks to our listeners for sticking with us through a dense topic. We'll be back tomorrow with another angle.